Detecting and correcting vibration in heat exchangers

ABSTRACT

A plant or refinery may include equipment such as reactors, heaters, heat exchangers, regenerators, separators, or the like. Types of heat exchangers include shell and tube, plate, plate and shell, plate fin, air cooled, wetted-surface air cooled, or the like. Operating methods may impact deterioration in equipment condition, prolong equipment life, extend production operating time, or provide other benefits. Mechanical or digital sensors may be used for monitoring equipment, and sensor data may be programmatically analyzed to identify developing problems. For example, sensors may be used in conjunction with one or more system components to detect and correct maldistribution, cross-leakage, strain, pre-leakage, thermal stresses, fouling, vibration, problems in liquid lifting, conditions that can affect air-cooled exchangers, conditions that can affect a wetted-surface air-cooled heat exchanger, or the like. An operating condition or mode may be adjusted to prolong equipment life or avoid equipment failure.

CROSS-REFERENCE TO RELATED APPLICATION

This is a continuation of U.S. application Ser. No. 15/937,579, filedMar. 27, 2018, which claims the benefit of priority under 35 U.S.C. §119(e) of U.S. Provisional Application No. 62/477,688, filed Mar. 28,2017, each of which is incorporated by reference in its entirety.

FIELD

The present disclosure is related to a method and system for managingthe operation of a plant, such as a chemical plant or a petrochemicalplant or a refinery, and more particularly to a method for improving theperformance of components that make up operations in a plant. Typicalplants may be those that provide catalytic dehydrogenation orhydrocarbon cracking, or catalytic reforming, or other process units.

BACKGROUND

A plant or refinery may include one or more pieces of equipment forperforming a process. Equipment may break down over time, and need to berepaired or replaced. Additionally, a process may be more or lessefficient depending on one or more operating characteristics. There willalways be a need for improving process efficiencies and improvingequipment reliability.

SUMMARY

The following summary presents a simplified summary of certain features.The summary is not an extensive overview and is not intended to identifykey or critical elements.

One or more embodiments may include a system that includes a reactor; aheater; a heat exchanger; a regenerator; a separator; one or moresensors associated with the heat exchanger; a data collection platform;and/or a data analysis platform. The data collection platform mayinclude one or more processors of the data collection platform; acommunication interface of the data collection platform; and memorystoring executable instructions that, when executed, cause the datacollection platform to: receive, from the one or more sensors associatedwith the heat exchanger, sensor data comprising operation informationassociated with the heat exchanger; correlate the sensor data from theone or more sensors with metadata comprising time data, the time datacorresponding to the operation information associated with the heatexchanger; and transmit the sensor data. The data analysis platform mayinclude one or more processors of the data analysis platform; acommunication interface of the data analysis platform; and memorystoring executable instructions that, when executed, cause the dataanalysis platform to: receive, from the data collection platform, thesensor data comprising the operation information associated with theheat exchanger; analyze the sensor data to determine whether vibrationis occurring within the heat exchanger; based on determining that thevibration is occurring within the heat exchanger, determine arecommended adjustment to an operating condition of the heat exchangerto mitigate the vibration occurring within the heat exchanger; and senda command configured to cause the recommended adjustment to theoperating condition of the heat exchanger to mitigate the vibrationoccurring within the heat exchanger.

One or more embodiments may include one or more non-transitorycomputer-readable media storing executable instructions that, whenexecuted, cause a system to: receive sensor data comprising operationinformation associated with a heat exchanger; analyze the sensor data todetermine whether vibration is occurring within the heat exchanger;based on determining that the vibration is occurring within the heatexchanger, determine a recommended adjustment to an operating conditionof the heat exchanger to mitigate the vibration occurring within theheat exchanger; and send a command configured to cause the recommendedadjustment to the operating condition of the heat exchanger to mitigatethe vibration occurring within the heat exchanger.

One or more embodiments may include a method that includes receiving, bya data analysis computing device, sensor data comprising operationinformation associated with a heat exchanger; analyzing, by the dataanalysis computing device, the sensor data to determine whethervibration is occurring within the heat exchanger; based on determiningthat the vibration is occurring within the heat exchanger, determining,by the data analysis computing device, a recommended adjustment to anoperating condition of the heat exchanger to mitigate the vibrationoccurring within the heat exchanger; and sending, by the data analysiscomputing device, a command configured to cause the recommendedadjustment to the operating condition of the heat exchanger to mitigatethe vibration occurring within the heat exchanger.

Other technical features may be readily apparent to one skilled in theart from the following figures, descriptions, and claims.

BRIEF DESCRIPTION OF DRAWINGS

The present disclosure is illustrated by way of example and not limitedin the accompanying figures in which like reference numerals indicatesimilar elements and in which:

FIG. 1A depicts an illustrative arrangement for a catalyticdehydrogenation process in accordance with one or more exampleembodiments;

FIG. 1B depicts an illustrative arrangement for a fluid catalyticcracking process in accordance with one or more example embodiments;

FIG. 2 depicts an illustrative catalytic reforming process using a(vertically-oriented) combined feed-effluent (CFE) exchanger inaccordance with one or more example embodiments;

FIG. 3 depicts an illustrative an OLEFLEX process (catalyticdehydrogenation) with continuous catalyst regeneration (CCR) using a(vertically-oriented) hot combined feed-effluent (HCFE) exchanger inaccordance with one or more example embodiments;

FIG. 4 depicts an illustrative a vertical CFE heat exchanger having asingle tube pass design in accordance with one or more exampleembodiments;

FIGS. 5A and 5B depict illustrative baffle arrangements that may be usedin the heat exchanger of FIG. 4 in accordance with one or more exampleembodiments;

FIG. 6 depicts an illustrative vertical HCFE design having a single tubepass design in accordance with one or more example embodiments;

FIG. 7 depicts an illustrative PACKINOX welded plate heat exchanger witha single shell in accordance with one or more example embodiments;

FIG. 8 is a close up of the spray bar injection system of FIG. 7 fordistributing liquid feed into the welded plate heat exchanger inaccordance with one or more example embodiments;

FIG. 9 depicts an illustrative exploded view of a COMPLABLOC weldedplate block heat exchanger in accordance with one or more exampleembodiments;

FIG. 10A depicts an illustrative brazed aluminum plate fin heatexchangers (BAHX) where multiple streams are passed through the heatexchanger in accordance with one or more example embodiments;

FIG. 10B shows plate fins utilized in BAHX in accordance with one ormore example embodiments;

FIGS. 11A and 11B depicts channels of an illustrative diffusion bondedheat exchangers in accordance with one or more example embodiments;

FIG. 12 depicts an illustrative cross view of a floating tube sheetshell and tube type exchanger in accordance with one or more exampleembodiments;

FIGS. 13A and 13B depicts an illustrative spiral plate heat exchanger inaccordance with one or more example embodiments;

FIGS. 14A and 14B depict vaporizers in accordance with one or moreexample embodiments;

FIG. 15 depicts an illustrative air-cooled heat exchanger in accordancewith one or more example embodiments;

FIG. 16A depicts an illustrative computing environment for managing theoperation of one or more pieces of equipment in a plant in accordancewith one or more example embodiments;

FIG. 16B depicts an illustrative data collection computing platform forcollecting data related to the operation of one or more pieces ofequipment in a plant in accordance with one or more example embodiments;

FIG. 16C depicts an illustrative data analysis computing platform foranalyzing data related to the operation of one or more pieces ofequipment in a plant in accordance with one or more example embodiments;

FIG. 16D depicts an illustrative data analysis computing platform foranalyzing data related to the operation of one or more pieces ofequipment in a plant in accordance with one or more example embodiments;

FIG. 16E depicts an illustrative control computing platform forcontrolling one or more parts of one or more pieces of equipment in aplant in accordance with one or more example embodiments;

FIGS. 17A and 17B depict an illustrative flow diagram of one or moresteps that one or more devices may perform in controlling one or moreaspects of a plant operation in accordance with one or more exampleembodiments;

FIGS. 18 and 19 depict illustrative graphical user interfaces related toone or more aspects of a plant operation in accordance with one or moreexample embodiments; and

FIG. 20 depicts an illustrative flowchart of a process that one or moredevices may perform in controlling one or more aspects of a plantoperation in accordance with one or more example embodiments.

DETAILED DESCRIPTION

In the following description of various illustrative embodiments,reference is made to the accompanying drawings, which form a parthereof, and in which is shown, by way of illustration, variousembodiments in which aspects of the disclosure may be practiced. It isto be understood that other embodiments may be utilized, and structuraland functional modifications may be made, without departing from thescope of the present disclosure.

It is noted that various connections between elements are discussed inthe following description. It is noted that these connections aregeneral and, unless specified otherwise, may be direct or indirect,wired or wireless, and that the specification is not intended to belimiting in this respect.

A chemical plant or a petrochemical plant or a refinery may include oneor more pieces of equipment that process one or more input chemicals tocreate one or more products. For example, catalytic dehydrogenation canbe used to convert paraffins to the corresponding olefin, e.g., propaneto propene, or butane to butene.

A multitude of process equipment may be utilized in the chemical,refining, and petrochemical industry including, but not limited to,slide valves, rotating equipment, pumps, compressors, heat exchangers,fired heaters, control valves, fractionation columns, reactors, and/orshut-off valves.

Elements of chemical and petrochemical/refinery plants may be exposed tothe outside and thus can be exposed to various environmental stresses.Such stresses may be weather related, such as temperature extremes (hotand cold), high-wind conditions, and precipitation conditions such assnow, ice, and rain. Other environmental conditions may be pollutionparticulates, such as dust and pollen, or salt if located near an ocean,for example. Such stresses can affect the performance and lifetime ofequipment in the plants. Different locations may have differentenvironmental stresses. For example, a refinery in Texas may havedifferent stresses than a chemical plant in Montana.

Process equipment may deteriorate over time, affecting the performanceand integrity of the process. Such deteriorating equipment mayultimately fail, but before failing, may decrease efficiency, yield,and/or product properties.

FIG. 1A shows one typical arrangement for a catalytic dehydrogenationprocess 5. The process 5 includes a reactor section 10, a catalystregeneration section 15, and a product recovery section 20.

The reactor section 10 includes one or more reactors 25. A hydrocarbonfeed 30 is sent to a heat exchanger 35 where it exchanges heat with areactor effluent 40 to raise the feed temperature. The feed 30 is sentto a preheater 45 where it is heated to the desired inlet temperature.The preheated feed 50 is sent from the preheater 45 to the first reactor25. Because the dehydrogenation reaction is endothermic, the temperatureof the effluent 55 from the first reactor 25 is less than thetemperature of the preheated feed 50. The effluent 55 is sent tointerstage heaters 60 to raise the temperature to the desired inlettemperature for the next reactor 25.

After the last reactor, the reactor effluent 40 is sent to the heatexchanger 35, and heat is exchanged with the feed 30. The reactoreffluent 40 is then sent to the product recovery section 20. Thecatalyst 65 moves through the series of reactors 25. When the catalyst70 leaves the last reactor 25, it is sent to the catalyst regenerationsection 15. The catalyst regeneration section 15 includes a regenerator75 where coke on the catalyst is burned off and the catalyst may gothrough a reconditioning step. A regenerated catalyst 80 is sent back tothe first reactor 25.

The reactor effluent 40 is compressed in the compressor or centrifugalcompressor 82. The compressed effluent 115 is introduced to a cooler120, for instance a heat exchanger. The cooler 120 lowers thetemperature of the compressed effluent. The cooled effluent 125 (cooledproduct stream) is then introduced into a chloride remover 130, such asa chloride scavenging guard bed. The chloride remover 130 includes anadsorbent, which adsorbs chlorides from the cooled effluent 125 andprovides a treated effluent 135. Treated effluent 135 is introduced to adrier 84.

The dried effluent is separated in separator 85. Gas 90 is expanded inexpander 95 and separated into a recycle hydrogen stream 100 and a netseparator gas stream 105. A liquid stream 110, which includes the olefinproduct and unconverted paraffin, is sent for further processing, wherethe desired olefin product is recovered and the unconverted paraffin isrecycled to the dehydrogenation reactor 25.

FIG. 1B shows a typical fluid catalytic cracking (FCC) process whichincludes an FCC fluidized bed reactor and a spent catalyst regenerator.Regenerated cracking catalyst entering the reactor, from the spentcatalyst regenerator, is contacted with an FCC feed stream in a risersection at the bottom of the FCC reactor, to catalytically crack the FCCfeed stream and provide a product gas stream, comprising crackedhydrocarbons having a reduced molecular weight, on average, relative tothe average molecular weight of feed hydrocarbons in the FCC feedstream. As shown in FIG. 1B, steam and lift gas are used as carriergases that upwardly entrain the regenerated catalyst in the risersection, as it contacts the FCC feed. In this riser section, heat fromthe catalyst vaporizes the FCC feed stream, and contact between thecatalyst and the FCC feed causes cracking of this feed to lowermolecular weight hydrocarbons, as both the catalyst and feed aretransferred up the riser and into the reactor vessel. A product gasstream comprising the cracked (e.g., lower molecular weight)hydrocarbons is separated from spent cracking catalyst at or near thetop of the reactor vessel, preferably using internal solid/vaporseparation equipment, such as cyclone separators. This product gasstream, essentially free of spent cracking catalyst, then exits thereactor vessel through a product outlet line for further transport tothe downstream product recovery section.

The spent or coked catalyst, following its disengagement or separationfrom the product gas stream, requires regeneration for further use. Thiscoked catalyst first falls into a dense bed stripping section of the FCCreactor, into which steam is injected, through a nozzle and distributor,to purge any residual hydrocarbon vapors that would be detrimental tothe operation of the regenerator. After this purging or strippingoperation, the coked catalyst is fed by gravity to the catalystregenerator through a spent catalyst standpipe. FIG. 1B depicts aregenerator, which can also be referred to as a combustor. Regeneratorsmay have various configurations. In the spent catalyst regenerator, astream of oxygen-containing gas, such as air, is introduced to contactthe coked catalyst, burn coke deposited thereon, and provide regeneratedcatalyst, having most or all of its initial coke content converted tocombustion products, including CO2, CO, and H2O vapors that exit in aflue gas stream. The regenerator operates with catalyst and theoxygen-containing gas (e.g., air) flowing upwardly together in acombustor riser that is located within the catalyst regenerator. At ornear the top of the regenerator, following combustion of the catalystcoke, regenerated cracking catalyst is separated from the flue gas usinginternal solid/vapor separation equipment (e.g., cyclones) to promoteefficient disengagement between the solid and vapor phases.

In the FCC recovery section, the product gas stream exiting the FCCreactor is fed to a bottoms section of an FCC main fractionation column.Several product fractions may be separated on the basis of theirrelative volatilities and recovered from this main fractionation column.Representative product fractions include, for example, naphtha (or FCCgasoline), light cycle oil, and heavy cycle oil.

Other petrochemical processes produce desirable products, such asturbine fuel, diesel fuel and other products referred to as middledistillates, as well as lower boiling hydrocarbon liquids, such asnaphtha and gasoline, by hydrocracking a hydrocarbon feedstock derivedfrom crude oil or heavy fractions thereof. Feedstocks most oftensubjected to hydrocracking are the gas oils and heavy gas oils recoveredfrom crude oil by distillation.

References herein to a “plant” are to be understood to refer to any ofvarious types of chemical and petrochemical manufacturing or refiningfacilities. References herein to a plant “operators” are to beunderstood to refer to and/or include, without limitation, plantplanners, managers, engineers, technicians, and others interested in,overseeing, and/or running the daily operations at a plant.

Heat Exchangers

Heat Exchangers have many purposes in chemical and petrochemical plants.There are many different types of heat exchangers with the selectionbased on the specifics of its intended purpose. A typical use is toincrease the temperature of the feed stream and reduce the temperatureof a product stream or intermediate stream. For example, for a combinedfeed-effluent exchanger (CFE), an upstream process unit, or afractionation column, or a pump may be directly upstream for the coldfeed inlet; a recycle gas compressor is upstream of the cold recycle gasinlet; a fired heater is downstream of the cold outlet; a reactor isupstream of the hot effluent inlet; a product condenser (air-cooled,water-cooled, or both) is downstream of the hot effluent outlet.

Heat exchangers may be classified by their flow arrangement. Flowschemes reference how the hot stream and the cold stream are arranged(and therefore affect the temperature difference driving force for heattransfer between the two streams), and can refer to either overall flowthrough the exchanger (nozzle to nozzle) or locally (within a bafflecross-pass or a plate pass).

Parallel flow refers to two flows traveling in the same direction.Counter flow refers to two flows traveling in opposite directions. Crossflow refers to two (typically locally) flows that are perpendicular toeach other.

Types of heat exchangers include, but are not limited to, shell and tubeheat exchangers, plate heat exchangers, plate and shell heat exchangers,plate fin heat exchangers, and/or air cooled heat exchangers. Metalplates form the bundle and channels between the plates form the passagesfor flow. Other heat exchangers may be air-cooled heat exchangers andwetted surface air coolers. The heat exchangers may be verticallyoriented or horizontally oriented.

Particular types of heat exchangers include combined feed exchangers(horizontal shells in series), column reboiler, column condenser, columntrim condenser, column feed-bottoms exchanger, column bottoms cooler,feed heater, effluent cooler, chiller, cooler, heater, and vaporizer.Air exchangers typically use ambient air to cool streams of gas orliquid. A cold box combines brazed heat exchangers with any type ofcomplementary cryogenic equipment, such as knock-out drums, two-phaseinjection drums, distillation columns, interconnecting piping, valvesand instrumentation, for example used to separate product streams atcold temperatures.

In some aspects, a cold stream, which is a mixture of feed and recyclegas, needs to be heated and a hot stream, which is reactor effluent,needs to be cooled. The recycle gas is typically hydrogen-rich recyclegas. The feed may be liquid feed or gas feed which is mixed then withthe recycle gas. If a liquid feed the combined feed and recycle gasforms a two phase system. The temperatures of the feed/recycle gas andeffluent entering the exchanger depend on the particular process.

Vertically oriented heat exchangers can be used in many processes,including hydrocarbon processes. Often, a vertically oriented exchangermay be used to preheat a mixed phase of a liquid hydrocarbon feed and agas rich in hydrogen. Typically, a vertically oriented exchanger is usedas a combined feed and effluent (hereinafter may be abbreviated “CFE”)exchanger where a mixed phase of a hydrocarbon liquid and a gas arepreheated with the effluent from a reactor. Often, a liquid hydrocarbonfeed and a gas, often a recycle gas including hydrogen, are mixed andintroduced on the tube side. Generally, the mixture requires good liftto pass upwards through the vertically oriented heat exchanger.

FIG. 2 illustrates a process for reforming with continuous catalystregeneration (CCR) using a (vertically oriented) combined feed-effluent(CFE) exchanger. The cold stream, a combination of liquid feed (110.4°C.) with hydrogen rich recycle gas (e.g., light paraffins) (125.8° C.),is introduced into a CFE exchanger where the feed is vaporized.(Entrance temperature: 96.9° C. Exit temperature: 499.6° C.) Thefeed/recycle exits the CFE as a gas and goes through a series of heatingand reaction steps. The resulting product effluent or hot stream isintroduced into the CFE exchanger and is cooled down. (Entrancetemperature: 527.9° C. Exit temperature: 109.1° C.) The effluent exitsthe CFE exchanger and is then cooled down further and condensed using anair cooler. The liquid product is separated from the gas streamcontaining hydrogen and light paraffins. Some of the gas stream isremoved, for example as a product, and the rest of the stream is used asrecycle gas.

FIG. 3 illustrates a catalytic dehydrogenation process (e.g., an OLEFLEXprocess) with continuous catalyst regeneration (CCR) using a(vertically-oriented) hot combined feed-effluent (HCFE) exchanger. Thecold stream, a combination of vapor feed with hydrogen rich recycle gas,is introduced into a HCFE exchanger and is heated. (Entrancetemperature: 39.7° C. Exit temperature: 533.7° C.) The feed/recycleexits the HCFE as a gas and goes through a series of heating andreaction steps. The resulting product effluent or hot stream isintroduced into the HCFE exchanger and is cooled down. (Entrancetemperature: 583.7° C. Exit temperature: 142.3° C.) The effluent exitsthe HCFE exchanger and is then cooled down further using an air cooler.The effluent then passes through a dryer, separators, and strippers.Hydrogen recycle gas is separated after the dryer and returned to thefeed stream.

Combined feed—effluent heat exchanger services are found in variousprocess units (some examples are listed below), having different CFEprocess conditions. The entrance and exit temperatures of the heatexchangers depend on the feed composition, recycle gas, and producteffluent as well as reaction conditions and process parameters. Forexample inlet/outlet temperatures may be:

a. Isomerization of xylenes:

-   -   i. (Cold stream) Mix of Recycle Gas and Feed 143.1° C./401.0° C.        -   1. H2 rich Recycle Gas 70.1° C.        -   2. Liquid Feed 180.3° C.    -   ii. (Hot stream) Reactor Effluent 443.9° C./166.6° C.

b. Transalkylation of toluene and other aromatics

-   -   i. (Cold stream) Mix of Recycle Gas and Feed 112.5° C./457.9° C.        -   1. H2 rich Recycle Gas 57.4° C.        -   2. Liquid Feed 164.2° C.    -   ii. (Hot stream) Reactor Effluent 492.9° C./136.9° C.

c. OLEFLEX CCFE in Cold Box: (Catalytic dehydrogenation—cold combinedfeed heat exchanger)

-   -   i. (Cold stream) Mix of Recycle Gas and Feed −93.2° C./38.0° C.        -   1. (Cold stream) H2 rich Recycle Gas −112.1° C.        -   2. (Cold stream) Liquid Feed −89.2° C.    -   ii. (Cold stream) Net Gas −121.6° C./27.4° C.    -   iii. (Hot stream) Reactor Effluent 42.6° C./−92.0° C.

Heat exchangers may be made of any material of construction used in achemical plant, refinery or petrochemical plant. Such constructionmaterial include carbon steel, stainless steel (typical for weldedplates exchangers to manage thickness and strength), low chrome carbonsteels, mid chrome carbon steels, austenitic stainless steels, highalloys, copper alloys, nickel alloys and titanium. Brazed aluminumexchangers are typically aluminum, and diffusion bonded exchangers aretypically stainless steels.

Special devices may be used to obtain uniform distribution of liquid andvapor. In some exchangers, spray bars are used to spray and mix liquidfeed into the vapor recycle gas as it enters the bundle. In a verticaltubular combined feed-effluent (VCFE) a spray pipe or liquid distributorprovides a similar function. In a brazed aluminum or diffusion bondedexchanger spray holes or special fin geometry may be used to mix liquidand vapor streams (from separate inlet headers) at the inlet to thepassages. In shell and tube exchangers, spray nozzles may be used todistribute a solvent (or wash water) into an exchanger to controlfouling.

The spray bar or spray pipe may include covers or sleeves that can openand close holes that make up the spray nozzles. Operation of thesecovers can be maintained through use of a processor. The covers can beopened and closed to direct flow and restrict flow to different areas ofthe heat exchanger. In one aspect, a single cover will cover severalholes at once. In another aspect, a single cover will cover only onehole.

Vertical CFE

FIG. 4 is an example of a vertical CFE heat exchanger having a singletube pass design. Typically, there is one shell in series but there maybe multiple (1 to 4) shells in parallel. Normal operating heat transfercoefficient may be 35-50 Btu/hr-ft2-° F. Normal operating meantemperature difference may be about 80° F. Normal operating pressuredrop may be 10.5-12.5 psi total.

Expansion bellows are located inside the device adjacent the feed pipeinlet to accommodate expansion/contraction due to differential thermalexpansion and fluctuating temperature conditions. The feed and recyclegas is distributed to the tubes via a spray pipe distributor and/ororifice plate. A shell side girth flange connects the upper and lowerparts of the shell. The upper and lower parts are made of differentmetallurgy (e.g., CR/MO, carbon steel, respectively). The feed entersthe bottom of the heat exchanger, flows through a distributor andthrough the tubes, and exits at the top. The product effluent enters atthe top of the heat exchanger and has a circuitous path around bafflearrangements. Baffle arrangements may take various forms andconstructions as seen in FIGS. 5A and 5B.

Although not as common, multiple shells may be used in series. In thiscase, by-pass pipes may be used in case one of the exchangers in theseries must be taken offline, for example for maintenance.

Vertical HCFE

FIG. 6 is an example of a vertical HCFE design having a single tube passdesign. Normal operating heat transfer coefficient may be 20-25Btu/hr-ft2-° F. Normal operating mean temperature difference may beabout 100° F. Normal operating pressure drop may be 2-3 psi total.

Expansion bellows are located inside the device adjacent the feed pipeinlet to accommodate expansion/contraction due to differential thermalexpansion and fluctuating temperature conditions. A shell side girthflange connects upper and lower parts of the shell. The upper and lowerparts are made of different metallurgy (e.g., stainless steel, carbonsteel, respectively). The feed enters the bottom of the heat exchanger,has a circuitous path around baffle arrangements, and exits at the top.The product effluent enters at the top, flows through the tubes, andexits at the bottom.

PACKINOX Welded Plate Heat Exchanger

FIG. 7 is an example of a PACKINOX welded plate heat exchanger with asingle shell. Normal operating heat transfer coefficient may be twotimes or three times or more than the coefficients achieved with shelland tube type heat exchangers. Normal operating mean temperaturedifference may be less that about 60° F. Normal operating pressure dropmay be 12.5 psi total.

Expansion bellows are located inside the device adjacent inlets andoutlets to accommodate expansion/contraction due to differential thermalexpansion and fluctuating temperature conditions. The feed and recyclegas enters the bottom of the device, flows in channels between plates,and exits at the top. The product effluent enters at the top, flows indifferent channels between the plates, and exits at the bottom.

FIG. 8 depicts a spray bar injection system for distributing the liquidfeed to channels between the plates and grids having holes to distributethe recycle gas to channels between the plates. The liquid is dispersedand the recycle gas carries the liquid upward between channels betweenthe plates. In the heat exchanger of FIG. 7, two spray bars are oftenused.

COMPLABLOC

FIG. 9 depicts an exploded view of a COMPLABLOC welded plate heatexchanger. This heat exchanger is typically used for chemicallyaggressive environments and low to moderate temperatures. The COMPLABLOCheat exchanger is a welded plate heat exchanger with no gaskets betweenthe plates. The plates are welded alternatively to form channels. Theframe has four corner girders, top and bottom heads and four side panelswith nozzle connections. These components are bolted together and can bequickly taken apart for inspection, service or cleaning. This allows forcompactness of surface yet is reasonably cleanable. The size andpressure, however, is somewhat restricted by the flat bolted covers thatare needed. Flow enters the heat exchanger and is guided betweenalternating plates. The flow may be reversed several times until itexits at the other end of the heat exchanger. COMPABLOC exchangers arecapable of obtaining higher heat transfer coefficients and smalleroperating mean temperature differences with the similar pressure dropscompared to shell and tube heat exchangers.

Multi-Stream Heat Exchangers

Multi-stream heat exchangers are configured so multiple streams arepassed through the heat exchanger. A multi-stream service has more thantwo streams and may be more than 12 streams. Normal operating heattransfer coefficients, operating mean temperature differences andpressure drops depend on the individual streams being considered andwill vary from stream to stream. They are typically similar to thevalues obtained in other plate type heat exchangers. Multi-stream heatexchangers include brazed aluminum plate fin heat exchangers (BAHX) anddiffusion bonded heat exchangers.

FIG. 10A is an example of a brazed aluminum plate fin heat exchangers(BAHX) typically used for air separation and cryogenic applications.FIG. 10B shows a close up view of the plate fins. Brazed heat exchangershave very low service temperature limits and may have a multiplestreams, as many as dozen or more streams, all chilled by a common coldstream or streams in one exchanger instead of multiple exchangers.Alternatively, multiple streams may all be heated by a common hot streamor streams in one exchanger.

FIG. 11A and FIG. 11B depict diffusion bonded heat exchangers that aretypically used for off-shore platform applications and include printedcircuit heat exchangers (PCHE) and formed plate heat exchangers (FPHE.)Diffusion bonding is a solid state joining process which gives rise toparent metal strength via clean high temperature and pressure. Thebonding does not involve melting or deformation and does not use braze,flux, or filler. The process promotes grain strength across the plateinterface.

Shell & Tube Exchanger

FIG. 12 depicts a cross view of a cross-flow floating tube sheet typeshell and tube exchanger. This is a cross flow exchanger as the flowentering the shell takes a circuitous path around baffles and crossingover tubes carrying a flow across the exchanger. This exchanger as shownhas a four-pass flow on the tube side, and other quantities of tube sidepasses are possible. The tube may be a bundle of tubes that extendacross the exchanger. The tubes extend between a stationary tube sheetand a floating tubesheet. The floating tubesheet and floating head coverallow for expansion and contraction of the tubes relative to the shell.

Spiral Plate Heat Exchanger

FIG. 13A depicts a spiral plate heat exchanger. A spiral plate heatexchanger has two spiral channels that are concentric, one for eachfluid. The curved channels provide great heat transfer and flowconditions for a wide variety of fluids. The spiral plate heat exchangertypically has a single passage for each fluid, making it a good choicefor fouling fluids or fluids containing solid particles. The overallsize of the unit is kept to a minimum therefore optimizing space. Spiralplate exchangers are easy to open to clean. FIG. 13B shows the studsused to maintain plate spacing.

Vaporizers

FIGS. 14A and 14B depict bayonet type vaporizers. FIG. 14A depicts atypical vaporizer. A depicts an inlet for the process stream beingvaporized. B is an outlet for the same stream. C is a vent. D and Erepresent level gauge and level control connections respectively. F is aside drain. Steam enters through H. Condensate is removed through G viachest drain.

FIG. 14B depicts a bayonet type tube. Steam enters the inner tube andflows upward. The top of the inner tube is open so the steam flowsdownward in the annular space. The steam is condensed in this area. Thelevel liquid level (condensate) is controlled below top of bayonettubes. A small amount of vapor superheat is possible as a portion of thebayonet tube extends above the liquid level and continues to heat thevaporized process stream.

Problems Encountered—Generally

Heat exchangers are subjected to various issues, including but notlimited to maldistribution, thermal stress, fouling, strain, vibrations,and corrosion, which can affect their performance or result in crossleakage and ultimately failure of components of the heat exchange unit.

For example, corrosive agents in flow streams through the heat exchangermay corrode tubes or plates, compromising their integrity, resulting incross-leaks or leaks to the outside. Fouling is the accumulation ofunwanted substances on surfaces inside the tubes, outside the tubes, oron surfaces of plates. Fouling or formation of a thin coating addsresistance to heat transfer. Fouling can lead to plugging that canultimately lead to higher pressure drop, reduced capacity or throughput,and to a blockage of the flow. Plugging may also occur from feedmaterial that accumulates on the inside of tubes or channels. Foulingand plugging may also lead to flow maldistribution. Flow maldistributionmay lead to poor performance, or to thermal stresses that can causemechanical damage. Other damage potentially caused by fouling includespermanent damage to the exchanger bundle, where the insides of tubes, oroutsides of tube, or plate channels cannot be effectively cleaned, inthese cases, the exchanger, or the bundle, may need to be replaced.Damage to the process, for example not meeting product specifications,and damage to downstream equipment, for example fired heaters orreactors, may also result from fouling of a heat exchanger.

Mechanical damage, corrosion, failure of internal sealing devices, andthermal or mechanical stresses to the heat exchanger may all lead tocross-leakage, in particular in areas of connections between differentparts and/or different metallurgies.

Tubes, plates, flanges, and pressure boundary materials may be subjectedto strain due to thermal stresses. Thermal stresses are stresses causedby differential thermal growth between parts that are at differenttemperatures or of different materials, due to excessively high or lowtemperatures, or an excessive temperature differential (delta), or rapidchanges in temperature conditions between streams in the heat exchanger,or maldistribution of flow within the heat exchanger (e.g., coolantflowing to some passages or tubes, and not to others).

Hot spots may form due to fouling, or maldistribution from manypotential causes, and in addition to thermal stresses, may result inweakening and ultimately failure of the material.

Representative locations of, for example, possible maldistribution(uneven flow), corrosion, fouling, thermal stresses, potential corrosionor foulants, and vibration, are indicated in the figures. These arerepresentative locations and not intended to be encompassing of allpossible areas that may be subjected to various stresses or problems.

Monitoring

Monitoring the heat exchangers and the processes using heat exchangersmay be performed to determine if problems are occurring, if equipmentfailures are imminent, if there is vibration, if there ismaldistribution, if there is fouling, or the like. Monitoring also helpsto collect data that can be correlated and used to predict behavior orproblems in different heat exchangers used in the same plant or in otherplants and/or processes.

There may or may not be anything that can be done to correct issues orproblems associated with the issues in existing equipment, depending onthe cause of the issues. In some aspects, process changes or operatingconditions may be able to be altered to preserve the equipment until thenext scheduled maintenance period. For example, streams may be monitoredfor corrosive contaminants, and pH may be monitored in order to predicthigher than normal corrosion rates within the heat exchanger equipment.Tracking production rates, flow rates, and/or temperature may indicateissues with flows. For example, as fouling occurs, the production ratemay fall if a specific outlet temperature can no longer be achieved atthe targeted capacity and capacity has to be reduced to maintain thetargeted outlet temperature.

Sensor Data Collection and Processing

The system may include one or more computing devices or platforms forcollecting, storing, processing, and analyzing data from one or moresensors. FIG. 16A depicts an illustrative computing system that may beimplemented at one or more components, pieces of equipment (e.g., heatexchanger), and/or plants. FIG. 16A-FIG. 16E (hereinafter collectively“FIG. 16”), show, by way of illustration, various components of theillustrative computing system in which aspects of the disclosure may bepracticed. It is to be understood that other components may be used, andstructural and functional modifications may be made, in one or moreother embodiments without departing from the scope of the presentdisclosure. Moreover, various connections between elements are discussedin the following description, and these connections are general and,unless specified otherwise, may be direct or indirect, wired orwireless, and/or combination thereof, and that the specification is notintended to be limiting in this respect.

FIG. 16A depicts an illustrative operating environment in which variousaspects of the present disclosure may be implemented in accordance withexample embodiments. The computing system environment 1000 illustratedin FIG. 16A is only one example of a suitable computing environment andis not intended to suggest any limitation as to the scope of use orfunctionality contained in the disclosure. The computing systemenvironment 1000 may include various sensor, measurement, and datacapture systems, a data collection platform 1002, a data analysisplatform 1004, a control platform 1006, one or more networks, one ormore remote devices 1054, 1056, and/or one or more other elements. Thenumerous elements of the computing system environment of FIG. 16A may becommunicatively coupled through one or more networks. For example, thenumerous platforms, devices, sensors, and/or components of the computingsystem environment may be communicatively coupled through a privatenetwork 1008. The sensors be positioned on various components in theplant and may communicate wirelessly or wired with one or more platformsillustrated in FIG. 16A. The private network 1008 may include, in someexamples, a network firewall device to prevent unauthorized access tothe data and devices on the private network 1008. Alternatively oradditionally, the private network 1008 may be isolated from externalaccess through physical means, such as a hard-wired network with noexternal, direct access point. The data communicated on the privatenetwork 1008 may be optionally encrypted for further security. Dependingon the frequency of collection and transmission of sensor measurementsand other data to the data collection platform 1002, the private network1008 may experience large bandwidth usage and be technologicallydesigned and arranged to accommodate for such technological issues.Moreover, the computing system environment 1000 may also include apublic network 1010 that may be accessible to remote devices (e.g.,remote device 1054, remote device 1056). In some examples, a remotedevice may be located not in the proximity (e.g., more than one mileaway) of the various sensor, measurement, and data capture systemsillustrated in FIG. 16A. In other examples, the remote device may bephysically located inside a plant, but restricted from access to theprivate network 1008; in other words, the adjective “remote,” need notnecessarily require the device to be located at a great distance fromthe sensor systems and other components.

Although the computing system environment of FIG. 16A illustrateslogical block diagrams of numerous platforms and devices, the disclosureis not so limited. In particular, one or more of the logical boxes inFIG. 16 may be combined into a single logical box or the functionalityperformed by a single logical box may be divided across multipleexisting or new logical boxes. For example, aspects of the functionalityperformed by the data collection platform 1002 may be incorporated intoone or each of the sensor devices illustrated in FIG. 16A. As such, thedata collection may occur local to the sensor device, and the enhancedsensor system may communicate directly with one or more of the controlplatform 1006 and/or data analysis platform 1004. An illustrativeexample of such an embodiment is contemplated by FIG. 16A. Moreover, insuch an embodiment, the enhanced sensor system may measure values commonto a sensor, but may also filter the measurements such just those valuesthat are statistically relevant or of-interest to the computing systemenvironment are transmitted by the enhanced sensor system. As a result,the enhanced sensor system may include a processor (or other circuitrythat enables execution of computer instructions) and a memory to storethose instructions and/or filtered data values. The processor may beembodied as an application-specific integrated circuit (ASIC), FPGA, orother hardware- or software-based module for execution of instructions.In another example, one or more sensors illustrated in FIG. 16A may becombined into an enhanced, multi-purpose sensor system. Such a combinedsensor system may provide economies of scale with respect to hardwarecomponents such as processors, memories, communication interfaces, andothers.

In yet another example, the data collection platform 1002 and dataanalysis platform 1004 may reside on a single server computer anddepicted as a single, combined logical box on a system diagram.Moreover, a data store may be illustrated in FIG. 16A separate and apartfrom the data collection platform 1002 and data analysis platform 1004to store a large amount of values collected from sensors and othercomponents. The data store may be embodied in a database format and maybe made accessible to the public network 1010; meanwhile, the controlplatform 1006, data collection platform 1002, and data analysis platform1004 may be restricted to the private network 1008 and left inaccessibleto the public network 1010. As such, the data collected from a plant maybe shared with users (e.g., engineers, data scientists, others), acompany's employees, and even third parties (e.g., subscribers to thecompany's data feed) without compromising potential securityrequirements related to operation of a plant. The data store may beaccessible to one or more users and/or remote devices over the publicnetwork 1010.

Referring to FIG. 16A, process measurements from various sensor andmonitoring devices may be used to monitor conditions in, around, and onprocess equipment (e.g., heat exchanger). Such sensors may include, butare not limited to, pressure sensors 1024, differential pressure sensors1036, various flow sensors (including but not limited to orifice platetype 1013, disc sensors 1022, venturi 1038, other flow sensors 1030),temperature sensors 1012 including thermal cameras 1020 and skinthermocouples, capacitance sensors 1034, weight sensors 1032, gaschromatographs 1014, moisture sensors 1016, ultrasonic sensors 1018,position sensors, timing sensors, vibration sensors 1026, microphones1028, level sensors 1046, liquid level (hydraulic fluid) sensors, andother sensors used in the refining and petrochemical industry. Further,process laboratory measurements may be taken using gas chromatographs1014, liquid chromatographs, distillation measurements, octanemeasurements, and other laboratory measurements. System operationalmeasurements also can be taken to correlate the system operation to theheat exchanger measurements.

In addition, sensors may include transmitters and/or deviation alarms.One or more sensors may be programmed to set off an alarm or alert. Forexample, if an actuator fails, sensor data may be used to automaticallytrigger an alarm or alert (e.g., an audible alarm or alert, a visualalarm or alert). Other sensors may transmit signals to a processor or ahub that collects the data and sends to a processor. For example,temperature and pressure measurements may be sent to a hub (e.g., datacollection platform 1002). In one or more embodiments, temperaturesensors 1012 may include thermocouples, fiber optic temperaturemeasurement, thermal cameras 1020, and/or infrared cameras. Skinthermocouples may be applied to heat exchanger casing, or alternatively,to tubes, plates, or placed directly on a wall of a heat exchangercomponent. Alternatively, thermal (infrared) cameras 1020 may be used todetect temperature (e.g., hot spots) in all aspects of the equipment,including bundles (tubes). A shielded (insulated) tube skin thermocoupleassembly may be used to obtain accurate measurements. One example of athermocouple may be a removable XTRACTO Pad. A thermocouple can bereplaced without any additional welding. Clips and/or pads may be usedfor ease of replacement. Fiber Optic cable can be attached to the pipe,line, and/or vessel to provide a complete profile of temperatures.

Returning to FIG. 14A, sensors may be also used throughout a plant orheat exchanger to detect and monitor various issues such asmaldistribution, thermal stresses, vibration, fouling, and plugging.Sensors might be able to detect whether feed composition into theexchanger, such as pH, are outside of acceptable ranges leading to acorrosive environment or whether consumption of sacrificial anodes (inwater services) is nearing completion and resulting in a corrosiveenvironment. Sensors detecting outlet temperatures and pressure dropsmay be used to determine/predict flow and production rate changes.

Furthermore, flow sensors may be used in flow paths such as the inlet tothe path, outlet from the path, or within the path. If multiple tubesare used, the flow sensors may be placed in corresponding positions ineach of the tubes. In this manner, one can determine if one of the tubesis behaving abnormally compared to one or more other tubes. Flow may bedetermined by pressure-drop across a known resistance, such as by usingpressure taps. Other types of flow sensors include, but are not limitedto, ultrasonic, turbine meter, hot wire anemometer, vane meter, Kármán™,vortex sensor, membrane sensor (membrane has a thin film temperaturesensor printed on the upstream side, and one on the downstream side),tracer, radiographic imaging (e.g., identify two-phase vs. single-phaseregion of channels), an orifice plate (e.g., which may, in someexamples, be placed in front of or be integral to one or more tubes orchannels), pitot tube, thermal conductivity flow meter, anemometer,internal pressure flow profile, and/or measure cross tracer (measuringwhen the flow crosses one plate and when the flow crosses anotherplate).

The effect of flow vibrations may be detected and/or corrected. If theflow through the exchanger is not uniform, then high flow velocities cancause local vibration. This vibration can damage parts of the exchanger,such as tube, by many mechanisms, leading to leakage or cross-leakage ofexchangers. Flow-induced vibration is a large source of failure in shelland tube heat exchangers. Fluttering or resonance in the tubes may causevibration. In addition, equipment-induced vibration, such as mechanicalvibration (e.g., from nearby equipment, such as air compressors orrefrigeration machines, or from loose support structures) can cause avariety of damage. For example, welded pieces may crack or break loose.Mechanical vibration can cause tube failures (e.g., in the form of afatigue stress crack or erosion of tubing at the point of contact withbaffles). Flow vibration can lead to mal-distribution and cross-leakage.Flow vibration can accelerate dislodging of corrosion particles leadingto further corrosion or blocked flow. Flow vibration may ultimatelycrack plates, tubes, and baffles. Vibration may be detected withvibration sensors attached to the equipment such as plates, tubes,baffles, or shells. Flow vibration may further be detected using flowand pressure sensors in order to detect abnormalities in flow andpressure drop. In some embodiments, an enhanced sensor system maycomprise numerous of the aforementioned sensors in a single systemcomponent to provide improved sensory measurements and analytics.

In another example, strain sensors may measure the strain on a part. Forexample, a strain gauge may be built into heat exchanger plates andheaders. Measurements from such gauges may indicate whether a plate maybe getting ready to leak (pre-leakage), provide a prediction ofcross-leakage, or fail completely. Electrical strain gauges, forexample, are thin, rectangular-shaped strips of foil with maze-likewiring patterns on them leading to a couple of electrical cables. Astrain gauge may be more sensitive in a particular direction (e.g., astrain gauge may be more sensitive in a horizontal direction than avertical direction, or may be more sensitive in a vertical directionthan a horizontal direction). A strain gauge may include an electricalconductor (e.g., foil, semiconductor, or nanoparticle). The electricalconductor is applied to a component. When the component is strained, itswidth is changed. Specifically, for example, when the electricalconductor is subjected to a strain (e.g., compression or stretching) ina particular direction, the electrical conductor may increase ordecrease in electrical conductivity. The gauge's resistance willexperience a corresponding change (increased or decreased electricalconductivity), which allows for an amount of induced stress on thestrain gauge to be determined when a voltage is applied to the gauge.

Sensor data, process measurements, and/or calculations made using thesensor data or process measurements may be used to monitor and/orimprove the performance of the equipment and parts making up theequipment, as discussed in further detail below. For example, sensordata may be used to detect that a desirable or an undesirable chemicalreaction is taking place within a particular piece of equipment, and oneor more actions may be taken to encourage or inhibit the chemicalreaction. Chemical sensors may be used to detect the presence of one ormore chemicals or components in the streams, such as corrosive species,oxygen, hydrogen, and/or water (moisture). Chemical sensors may use gaschromatographs, liquid chromatographs, distillation measurements, and/oroctane measurements. In another example, equipment information, such aswear, efficiency, production, state, or other condition information, maybe gathered and determined based on sensor data. Corrective action maybe taken based on determining this equipment information. For example,if the equipment is showing signs of wear or failure, corrective actionsmay be taken, such as taking an inventory of parts to ensure replacementparts are available, ordering replacement parts, and/or calling inrepair personnel to the site. Certain parts of equipment may be replacedimmediately. Other parts may be safe to use, but a monitoring schedulemay be adjusted. Alternatively or additionally, one or more inputs orcontrols relating to a process may be adjusted as part of the correctiveaction. These and other details about the equipment, sensors, processingof sensor data, and actions taken based on sensor data are described infurther detail below.

Monitoring the heat exchangers and the processes using heat exchangersincludes collecting data that can be correlated and used to predictbehavior or problems in different heat exchangers used in the same plantor in other plants and/or processes. Data collected from the varioussensors (e.g., measurements such as flow, pressure drop, thermalperformance, vessel skin temperature at the top, expansion bellows leak,vibration, etc.) may be correlated with external data, such asenvironmental or weather data. Process changes or operating conditionsmay be able to be altered to preserve the equipment until the nextscheduled maintenance period. Fluids may be monitored for corrosivecontaminants and pH may be monitored in order to predict higher thannormal corrosion rates within the heat exchanger equipment. At a highlevel, sensor data collected (e.g., by the data collection platform) anddata analysis (e.g., by the data analysis platform) may be usedtogether, for example, for process simulation, equipment simulation,and/or other tasks. For example, sensor data may be used for processsimulation and reconciliation of sensor data. The resulting, improvedprocess simulation may provide a stream of physical properties that areused to calculate heat flow, etc. These calculations may lead to thermaland pressure drop performance prediction calculations for specificequipment, and comparisons of equipment predictions to observations fromthe operating data (e.g., predicted/expected outlet temperature andpressure vs. measured outlet temperature and pressure). This causesidentification of one or more of fouling, maldistribution, and/or otherissues that eventually lead to a potential control changes and/orrecommendation etc.

Systems Facilitating Sensor Data Collection

Sensor data may be collected by a data collection platform 1002. Thesensors may interface with the data collection platform 1002 via wiredor wireless transmissions. The data collection platform 1002 maycontinuously or periodically (e.g., every second, every minute, everyhour, every day, once a week, once a month) transmit collected sensordata to a data analysis platform 1004, which may be nearby or remotefrom the data collection platform 1002.

Sensor data (e.g., temperature data) may be collected continuously or atperiodic intervals (e.g., every second, every five seconds, every tenseconds, every minute, every five minutes, every ten minutes, everyhour, every two hours, every five hours, every twelve hours, every day,every other day, every week, every other week, every month, every othermonth, every six months, every year, or another interval). Data may becollected at different locations at different intervals. For example,data at a known hot spot may be collected at a first interval, and dataat a spot that is not a known hot spot may be collected at a secondinterval. The data collection platform may transmit collected sensordata to a data analysis platform, which may be nearby or remote from thedata collection platform.

The computing system environment of FIG. 16A includes logical blockdiagrams of numerous platforms and devices that are further elaboratedupon in FIG. 16B, FIG. 16C, FIG. 16D, and FIG. 16E. FIG. 16B is anillustrative data collection platform 1002. FIG. 16C is an illustrativedata analysis platform 1004. FIG. 16D is an illustrative controlplatform 1006. FIG. 16E is an illustrative remote device 1054. Theseplatforms and devices of FIG. 16 include one or more processing units(e.g., processors) to implement the methods and functions of certainaspects of the present disclosure in accordance with the exampleembodiments. The processors may include general-purpose microprocessorsand/or special-purpose processors designed for particular computingsystem environments or configurations. For example, the processors mayexecute computer-executable instructions in the form of software and/orfirmware stored in the memory of the platform or device. Examples ofcomputing systems, environments, and/or configurations that may besuitable for use with the disclosed embodiments include, but are notlimited to, personal computers (PCs), server computers, hand-held orlaptop devices, smart phones, multiprocessor systems,microprocessor-based systems, programmable consumer electronics, networkPCs, minicomputers, mainframe computers, distributed computingenvironments that include any of the above systems or devices, and thelike.

In addition, the platform and/or devices in FIG. 16 may include one ormore memories include any of a variety of computer-readable media.Computer-readable media may be any available media that may be accessedby the data collection platform 1002, may be non-transitory, and mayinclude volatile and nonvolatile, removable and non-removable mediaimplemented in any method or technology for storage of information suchas computer-readable instructions, object code, data structures,database records, program modules, or other data. Examples ofcomputer-readable media may include random access memory (RAM), readonly memory (ROM), electronically erasable programmable read only memory(EEPROM), flash memory or other memory technology, compact diskread-only memory (CD-ROM), digital versatile disks (DVD) or otheroptical disk storage, magnetic cassettes, magnetic tape, magnetic diskstorage or other magnetic storage devices, or any other medium that canbe used to store the desired information and that can be accessed by thedata collection platform 1002. The memories in the platform and/ordevices may further store modules that may include compiled softwarecode that causes the platform, device, and/or overall system to operatein a technologically improved manner as disclosed herein. For example,the memories may store software used by a computing platform, such asoperating system, application programs, and/or associated database.

Furthermore, the platform and/or devices in FIG. 16 may include one ormore communication interfaces including, but are not limited to, amicrophone, keypad, keyboard, touch screen, and/or stylus through whicha user of a computer (e.g., a remote device) may provide input, and mayalso include a speaker for providing audio output and a video displaydevice for providing textual, audiovisual and/or graphical output. Inputmay be received via one or more graphical user interfaces, which may bepart of one or more dashboards (e.g., dashboard 1003, dashboard 1005,dashboard 1007). The communication interfaces may include a networkcontroller for electronically communicating (e.g., wirelessly or wired)over a public network 1010 or private network 1008 with one or moreother components on the network. The network controller may includeelectronic hardware for communicating over network protocols, includingTCP/IP, UDP, Ethernet, and other protocols.

In some examples, one or more sensor devices in FIG. 16A may be enhancedby incorporating functionality that may otherwise be found in a datacollection platform 1002. These enhanced sensor system may providefurther filtering of the measurements and readings collected from theirsensor devices. For example, with some of the enhanced sensor systems inthe operating environment illustrated in FIG. 16A, an increased amountof processing may occur at the sensor so as to reduce the amount of dataneeding to be transferred over a private network 1008 in real-time to acomputing platform. The enhanced sensor system may filter at the sensoritself the measured/collected/captured data and only particular,filtered data may be transmitted to the data collection platform 1002for storage and/or analysis.

Referring to FIG. 16B, in one or more embodiments, a data collectionplatform 1002 may include one or more processors 1060, one or morememories 1062, and communication interfaces 1068. The memory 1062 mayinclude a database 1064 for storing data records of various valuescollected from one or more sources. In addition, a data collectionmodule 1066 may be stored in the memory 1062 and assist the processor1060 in the data collection platform 1002 in communicating with, via thecommunications interface 1068, one or more sensor, measurement, and datacapture systems, and processing the data received from these sources. Insome embodiments, the data collection module 1066 may includecomputer-executable instructions that, when executed by the processor1060, cause the data collection platform 1002 to perform one or more ofthe steps disclosed herein. In other embodiments, the data collectionmodule 1066 may be a hybrid of software-based and/or hardware-basedinstructions to perform one or more of the steps disclosed herein. Insome examples, the data collection module 1066 may assist an enhancedsensor system with further filtering the measurements and readingscollected from the sensor devices. Although the elements of FIG. 16B areillustrated as logical block diagrams, the disclosure is not so limited.In particular, one or more of the logical boxes in FIG. 16B may becombined into a single logical box or the functionality performed by asingle logical box may be divided across multiple existing or newlogical boxes. Moreover, some logical boxes that are visually presentedas being inside of another logical box may be moved such that they arepartially or completely residing outside of that logical box. Forexample, while the database 1064 in FIG. 16B is illustrated as beingstored inside one or more memories 1062 in the data collection platform1002, FIG. 16B contemplates that the database 1064 may be stored in astandalone data store communicatively coupled to the data collectionmodule 1066 and processor 1060 of the data collection platform 1002 viathe communications interface 1068 of the data collection platform 1002.

In addition, the data collection module 1066 may assist the processor1060 in the data collection platform 1002 in communicating with, via thecommunications interface 1068, and processing data received from othersources, such as data feeds from third-party servers and manual entry atthe field site from a dashboard graphical user interface (e.g., viadashboard 1003). For example, a third-party server may providecontemporaneous weather data to the data collection module. Someelements of chemical and petrochemical/refinery plants may be exposed tothe outside and thus may be exposed to various environmental stresses.Such stresses may be weather related such as temperature extremes (hotand cold), high wind conditions, and precipitation conditions such assnow, ice, and rain. Other environmental conditions may be pollutionparticulates such as dust and pollen, or salt if located near an ocean,for example. Such stresses can affect the performance and lifetime ofequipment in the plants. Different locations may have differentenvironmental stresses. For example, a refinery in Texas will havedifferent stresses than a chemical plant in Montana. In another example,data manually entered from a dashboard graphical user interface (e.g.,via dashboard 1003) (or other means) may be collected and saved intomemory by the data collection module. Production rates may be enteredand saved in memory. Tracking production rates may indicate issues withflows. For example, as fouling occurs, the production rate may fall if aspecific outlet temperature can no longer be achieved at the targetedcapacity and capacity has to be reduced to maintain the targeted outlettemperature.

Referring to FIG. 16C, in one or more embodiments, a data analysisplatform 1004 may include one or more processors 1070, one or morememories 1072, and communication interfaces 1082. The memory 1072 mayinclude a database 1074 for storing data records of various valuescollected from one or more sources. Alternatively or additionally, thedatabase 1074 may be the same database as that depicted in FIG. 16B andthe data analysis platform 1004 may communicatively couple with thedatabase 1074 via the communication interface of the data analysisplatform 1004. At least one advantage of sharing a database between thetwo platforms is the reduced memory requirements due to not duplicatingthe same or similar data. In addition, a data analysis module 1076 maybe stored in the memory 1072 and assist the processor 1070 in the dataanalysis platform 1004 in processing and analyzing the data valuesstored in the database 1074. In some embodiments, the data analysismodule 1076 may include computer-executable instructions that, whenexecuted by the processor 1070, cause the data analysis platform 1004 toperform one or more of the steps disclosed herein. In other embodiments,the data analysis module 1076 may be a hybrid of software-based and/orhardware-based instructions to perform one or more of the stepsdisclosed herein. In some embodiments, the data analysis module 1076 mayperform statistical analysis, predictive analytics, and/or machinelearning on the data values in the database 1074 to generate predictionsand models. For example, the data analysis platform 1004 may analyzesensor data to detect new hot spots and/or to monitor existing hot spots(e.g., to determine if an existing hot spot is growing, maintaining thesame size, or shrinking) in the equipment of a plant. The data analysisplatform 1004 may compare temperature or other data from different datesto determine if changes are occurring. Such comparisons may be made on amonthly, weekly, daily, hourly, real-time, or some other basis.

Referring to FIG. 16C, the recommendation module 1078 in the dataanalysis platform 1004 may coordinate with the data analysis module 1076to generate recommendations for adjusting one or more parameters for theoperation of the plant environment depicted in FIG. 16A. In someembodiments, the recommendation module 1078 may communicate therecommendation to the command module 1080, which may generate commandcodes that may be transmitted, via the communications interface, tocause adjustments or halting/starting of one or more operations in theplant environment. The command codes may be transmitted to a controlplatform 1006 for processing and/or execution. In one or moreembodiments, the command codes may be directly communicated, eitherwirelessly or in a wired fashion, to physical components at the plantsuch that the physical components include an interface to receive thecommands and execute on them.

Although the elements of FIG. 16C are illustrated as logical blockdiagrams, the disclosure is not so limited. In particular, one or moreof the logical boxes in FIG. 16C may be combined into a single logicalbox or the functionality performed by a single logical box may bedivided across multiple existing or new logical boxes. Moreover, somelogical boxes that are visually presented as being inside of anotherlogical box may be moved such that they are partially or completelyresiding outside of that logical box. For example, while the database isvisually depicted in FIG. 16C as being stored inside one or morememories in the data analysis platform 1004, FIG. 16C contemplates thatthe database may be stored in a standalone data store communicativelycoupled to the data analysis module and processor of the data analysisplatform 1004 via the communications interface of the data analysisplatform 1004. Furthermore, the databases from multiple plant locationsmay be shared and holistically analyzed to identify one or more trendsand/or patterns in the operation and behavior of the plant and/or plantequipment.

In such a crowdsourcing-type example, a distributed database arrangementmay be provided where a logical database may simply serve as aninterface through which multiple, separate databases may be accessed. Assuch, a computer with predictive analytic capabilities may access thelogical database to analyze, recommend, and/or predict the behavior ofone or more aspects of plants and/or equipment. In another example, thedata values from a database from each plant may be combined and/orcollated into a single database where predictive analytic engines mayperform calculations and prediction models.

Referring to FIG. 16D, in one or more embodiments, a control platform1006 may include one or more processors 1084, one or more memories 1086,and communication interfaces 1092. The memory 1086 may include adatabase 1088 for storing data records of various values transmittedfrom a user interface, computing device, or other platform. The valuesmay include parameter values for particular equipment at the plant. Forexample, some illustrative equipment at the plant that may be configuredand/or controlled by the control platform 1006 include, but is notlimited to, a feed switcher 1042, sprayer 1052, one or more valves 1044,one or more pumps 1040, one or more gates 1048, and/or one or moredrains 1050. In addition, a control module 1090 may be stored in thememory and assist the processor in the control platform 1006 inreceiving, storing, and transmitting the data values stored in thedatabase. In some embodiments, the control module 1090 may includecomputer-executable instructions that, when executed by the processor1084, cause the control platform 1006 to perform one or more of thesteps disclosed herein. In other embodiments, the control module may bea hybrid of software-based and/or hardware-based instructions to performone or more of the steps disclosed herein.

In a plant environment such as illustrated in FIG. 16A, if sensor datais outside of a safe range, this may be cause for immediate danger. Assuch, there may be a real-time component to the system such that thesystem processes and responds in a timely manner. Although in someembodiments, data could be collected and leisurely analyzed over alengthy period of months, numerous embodiments contemplate a real-timeor near real-time responsiveness in analyzing and generating alerts,such as those generated or received by the alert module in FIG. 16E.

Referring to FIG. 16E, in one or more embodiments, a remote device 1054may include one or more processors 1093, one or more memories 1094, andcommunication interfaces 1099. The memory 1094 may include a database1095 for storing data records of various values entered by a user orreceived through the communications interface. In addition, an alertmodule 1096, command module 1097, and/or dashboard module 1098 may bestored in the memory 1094 and assist the processor 1093 in the remotedevice 1054 in processing and analyzing the data values stored in thedatabase. In some embodiments, the aforementioned modules may includecomputer-executable instructions that, when executed by the processor,cause the remote device 1054 to perform one or more of the stepsdisclosed herein. In other embodiments, the aforementioned modules maybe a hybrid of software-based and/or hardware-based instructions toperform one or more of the steps disclosed herein. In some embodiments,the aforementioned modules may generate alerts based on values receivedthrough the communications interface. The values may indicate adangerous condition or even merely a warning condition due to odd sensorreadings. The command module 1097 in the remote device 1054 may generatea command that when transmitted through the communications interface tothe platforms at the plant, causes adjusting of one or more parameteroperations of the plant environment depicted in FIG. 16A. In someembodiments, the dashboard module 1098 may display a graphical userinterface to a user of the remote device 1054 to enable the user toenter desired parameters and/or commands. These parameters/commands maybe transmitted to the command module 1097 to generate the appropriateresulting command codes that may be then transmitted, via thecommunications interface, to cause adjustments or halting/starting ofone or more operations in the plant environment. The command codes maybe transmitted to a control platform 1006 for processing and/orexecution. In one or more embodiments, the command codes may be directlycommunicated, either wirelessly or in a wired fashion, to physicalcomponents at the plant such that the physical components include aninterface to receive the commands and execute them.

Although FIG. 16E is not so limited, in some embodiments the remotedevice 1054 may include a desktop computer, a smartphone, a wirelessdevice, a tablet computer, a laptop computer, and/or the like. Theremote device 1054 may be physically located locally or remotely, andmay be connected by one of communications links to the public network1010 that is linked via a communications link to the private network1008. The network used to connect the remote device 1054 may be anysuitable computer network including the Internet, an intranet, awide-area network (WAN), a local-area network (LAN), a wireless network,a digital subscriber line (DSL) network, a frame relay network, anasynchronous transfer mode (ATM) network, a virtual private network 1008(VPN), or any combination of any of the same. Communications links maybe any communications links suitable for communicating betweenworkstations and server, such as network links, dial-up links, wirelesslinks, hard-wired links, as well as network types developed in thefuture, and the like. Various protocols such as transmission controlprotocol/Internet protocol (TCP/IP), Ethernet, file transfer protocol(FTP), hypertext transfer protocol (HTTP) and the like may be used, andthe system can be operated in a client-server configuration to permit auser to retrieve web pages from a web-based server. Any of variousconventional web browsers can be used to display and manipulate data onweb pages.

Although the elements of FIG. 16E are illustrated as logical blockdiagrams, the disclosure is not so limited. In particular, one or moreof the logical boxes in FIG. 16E may be combined into a single logicalbox or the functionality performed by a single logical box may bedivided across multiple existing or new logical boxes. Moreover, somelogical boxes that are visually presented as being inside of anotherlogical box may be moved such that they are partially or completelyresiding outside of that logical box. For example, while the database isvisually depicted in FIG. 16E as being stored inside one or morememories in the remote device 1054, FIG. 16E contemplates that thedatabase may be stored in a standalone data store communicativelycoupled, via the communications interface, to the modules stored at theremote device 1054 and processor of the remote device 1054.

Referring to FIG. 16, in some examples, the performance of operation ina plant may be improved by using a cloud computing infrastructure andassociated methods, as described in US Patent Application PublicationNo. US2016/0260041, which was published Sep. 8, 2016, and which isherein incorporated by reference in its entirety. The methods mayinclude, in some examples, obtaining plant operation information fromthe plant and/or generating a plant process model using the plantoperation information. The method may include receiving plant operationinformation over the Internet, or other computer network (includingthose described herein) and automatically generating a plant processmodel using the plant operation information. These plant process modelsmay be configured and used to monitor, predict, and/or optimizeperformance of individual process units, operating blocks and/orcomplete processing systems. Routine and frequent analysis of predictedversus actual performance may further allow early identification ofoperational discrepancies, which may be acted upon to optimize impact.

The aforementioned cloud computing infrastructure may use a datacollection platform 1002 associated with a plant to capture data, e.g.,sensor measurements, which may be automatically sent to the cloudinfrastructure, which may be remotely located, where it may be reviewedto, for example, eliminate errors and biases, and used to calculate andreport performance results. The data collection platform 1002 mayinclude an optimization unit that acquires data from a customer site,other site, and/or plant (e.g., sensors and other data collectors at aplant) on a recurring basis. For cleansing, the data may be analyzed forcompleteness and corrected for gross errors by the optimization unit.The data may also be corrected for measurement issues (e.g., an accuracyproblem for establishing a simulation steady state) and overall massbalance closure to generate a duplicate set of reconciled plant data.The corrected data may be used as an input to a simulation process, inwhich the process model is tuned to ensure that the simulation processmatches the reconciled plant data. An output of the reconciled plantdata may be used to generate predicted data using a collection ofvirtual process model objects as a unit of process design.

The performance of the plant and/or individual process units of theplant is/are compared to the performance predicted by one or moreprocess models to identify any operating differences or gaps.Furthermore, the process models and collected data (e.g., plantoperation information) may be used to run optimization routines thatconverge on an optimal plant operation for a given values of, e.g.,feed, products, and/or prices. A routine may be understood to refer to asequence of computer programs or instructions for performing aparticular task.

The data analysis platform 1004 may include an analysis unit thatdetermines operating status, based on at least one of a kinetic model, aparametric model, an analytical tool, and/or a related knowledge and/orbest practice standard. The analysis unit may receive historical and/orcurrent performance data from one or a plurality of plants toproactively predict one or more future actions to be performed. Topredict various limits of a particular process and stay within theacceptable range of limits, the analysis unit may determine targetoperational parameters of a final product based on actual current and/orhistorical operational parameters. This evaluation by the analysis unitmay be used to proactively predict future actions to be performed. Inanother example, the analysis unit may establish a boundary or thresholdof an operating parameter of the plant based on at least one of anexisting limit and an operation condition. In yet another example, theanalysis unit may establish a relationship between at least twooperational parameters related to a specific process for the operationof the plant. Finally in yet another example, one or more of theaforementioned examples may be performed with or without a combinationof the other examples.

The plant process model predicts plant performance that is expectedbased upon the plant operation information. The plant process modelresults can be used to monitor the health of the plant and to determinewhether any upset or poor measurement occurred. The plant process modelis desirably generated by an iterative process that models at variousplant constraints to determine the desired plant process model.

Using a web-based system for implementing the method of this disclosuremay provide one or more benefits, such as improved plant performance dueto an increased ability by plant operators to identify and captureopportunities, a sustained ability to bridge plant performance gaps,and/or an increased ability to leverage personnel expertise and improvetraining and development. Some of the methods disclosed herein allow forautomated daily evaluation of process performance, thereby increasingthe frequency of performance review with less time and effort requiredfrom plant operations staff.

Further, the analytics unit may be partially or fully automated. In oneor more embodiments, the system is performed by a computer system, suchas a third-party computer system, remote from the plant and/or the plantplanning center. The system may receive signals and parameters via thecommunication network, and displays in real time related performanceinformation on an interactive display device accessible to an operatoror user. The web-based platform allows all users to work with the sameinformation, thereby creating a collaborative environment for sharingbest practices or for troubleshooting. The method further provides moreaccurate prediction and optimization results due to fully configuredmodels. Routine automated evaluation of plant planning and operationmodels allows timely plant model tuning to reduce or eliminate gapsbetween plant models and the actual plant performance. Implementing theaforementioned methods using the web-based platform also allows formonitoring and updating multiple sites, thereby better enabling facilityplanners to propose realistic optimal targets.

FIGS. 17A-17B depict illustrative system flow diagrams in accordancewith one or more embodiments described herein. As shown in FIG. 17A, instep 201, data collection platform 1002 may collect sensor data. In step202, data collection platform 1002 may transmit sensor data to dataanalysis platform 1004. In step 203, data analysis platform 1004 mayanalyze data. In step 204, data analysis platform 1004 may send an alertto remote device 1054 and/or remote device 1056.

As shown in FIG. 17B, in step 205, data analysis platform 1004 mayreceive a command from remote device 1054 and/or remote device 1056. Insome embodiments, the control platform 1006 may receive the command fromremote device 1054 and/or remote device 1056. In step 206, data analysisplatform 1004 may send a command to control platform 1006. In someembodiments, the command may be similar to the command received fromremote device 1054 and/or remote device 1056. In some embodiments, dataanalysis platform 1004 may perform additional analysis based on thereceived command from remote device 1054 and/or remote device 1056before sending a command to control platform 1006. In step 207, controlplatform 1006 may take corrective action. The corrective action may bebased on the command received from data analysis platform 1004, remotedevice 1054, and/or remote device 1056. The corrective action may berelated to one or more pieces of equipment (e.g., heat exchanger)associated with sensors that collected the sensor data in step 201.

FIG. 20 depicts an illustrative flow diagram in accordance with one ormore embodiments described herein. The flow may be performed by one ormore devices, which may be interconnected via one or more networks.

First, the one or more devices may collect 2102 sensor data. The sensordata may be from one or more sensors attached to one or more pieces ofequipment (e.g., a heat exchanger) in a plant. The sensor data may belocally collected and processed and/or may be locally collected andtransmitted for processing. The data may be collected on a periodicbasis.

After the sensor data is collected, the one or more devices may process2104 the sensor data. The one or more devices may compare the data topast data from the one or more pieces of equipment, other pieces ofequipment at a same plant, one or more pieces of equipment at adifferent plant, manufacturer recommendations or specifications, or thelike.

After the sensor data is processed, the one or more devices maydetermine 2106 one or more recommendations based on the sensor data. Theone or more recommendations may include recommendations of one or moreactions to take based on the sensor data.

The one or more devices may send 2108 one or more alerts, which mayinclude the determined recommendation. The one or more alerts mayinclude information about the sensor data, about other data, or thelike.

The data taken from one or more of the various sensors may be correlatedwith weather and environmental data to determine predictive models ofpotential problems in the current heat exchanger, and/or other heatexchanger used in different processes and environments.

The one or more devices may receive 2110 a command to take an action(e.g., the recommended action, an action other than the recommendedaction, or no action). After receiving the command, the one or moredevices may take 2112 the action. The action may, in some embodiments,include one or more corrective actions, which may cause one or morechanges in the operation of the one or more pieces of equipment. Thecorrective action(s) may be taken automatically or after userconfirmation, and/or the corrective action(s) may be taken without anaccompanying alert being generated (and vice-versa).

FIG. 18 depicts an illustrative graphical user interface 1900 of anapplication that may be used for providing information received from oneor more sensors or determined based on analyzing information receivedfrom one or more sensors, according to one or more embodiments describedherein. The graphical user interface may be displayed as part of asmartphone application (e.g., running on a remote device, such as remotedevice 1054 or remote device 1056), a desktop application, a webapplication (e.g., that runs in a web browser), a web site, anapplication running on a plant computer, or the like.

The graphical user interface 1900 may include one or more visualrepresentations of data (e.g., chart, graph, etc.) that showsinformation about a plant, a particular piece of equipment in a plant,or a process performed by a plant or a particular piece or combinationof equipment in the plant. For example, a graph may show informationabout an operating condition, an efficiency, a production level, or thelike. The graphical user interface 1900 may include a description of theequipment, the combination of equipment, or the plant to which thevisual display of information pertains.

The graphical user interface 1900 may display the information for aparticular time or period of time (e.g., the last five minutes, the lastten minutes, the last hour, the last two hours, the last 12 hours, thelast 24 hours, etc.). The graphical user interface may be adjustable toshow different ranges of time, automatically or based on user input.

The graphical user interface 1900 may include one or more buttons thatallow a user to take one or more actions. For example, the graphicaluser interface may include a button (e.g., an “Actions” button) that,when pressed, shows one or more actions available to the user. Thegraphical user interface may include a button (e.g., a “Change View”button) that, when pressed, changes one or more views of one or moreelements of the graphical user interface. The graphical user interfacemay include a button (e.g., a “Settings” button) that, when pressed,shows one or more settings of the application of which the graphicaluser interface is a part. The graphical user interface may include abutton (e.g., a “Refresh Data” button) that, when pressed, refreshesdata displayed by the graphical user interface. In some aspects, datadisplayed by the graphical user interface may be refreshed in real time,according to a preset schedule (e.g., every five seconds, every tenseconds, every minute, etc.), and/or in response to a refresh requestreceived from a user. The graphical user interface may include a button(e.g., a “Send Data” button) that, when pressed, allows a user to senddata to one or more other devices. For example, the user may be able tosend data via email, SMS, text message, iMessage, FTP, cloud sharing,AirDrop, or via some other method. The user may be able to select one ormore pieces of data, graphics, charts, graphs, elements of the display,or the like to share or send. The graphical user interface may include abutton (e.g., an “Analyze Data” button) that, when pressed, causes oneor more data analysis functions to be performed. In some aspects, theuser may provide additional input about the desired data analysis, suchas desired input, desired output, desired granularity, desired time tocomplete the data analysis, desired time of input data, or the like.

FIG. 19 depicts an illustrative graphical user interface 2000 of anapplication that may be used for providing alerts and/or receiving orgenerating commands for taking corrective action, in accordance with oneor more embodiments described herein. The graphical user interface 2000may include an alert with information about a current state of a pieceof equipment (e.g., a heat exchanger), a problem being experienced by apiece of equipment (e.g., a heat exchanger), a problem with a plant, orthe like. For example, the graphical user interface may include an alertthat a heat exchanger is experiencing maldistribution, cross-leakage,thermal stresses, fouling, vibration, liquid lift, that pre-leakage hasbeen detected, or another alert.

The graphical user interface 2000 may include one or more buttons that,when pressed, cause one or more actions to be taken. For example, thegraphical user interface 2000 may include a button that, when pressed,causes a flow rate to change. In another example, the graphical userinterface 2000 may include a button that, when pressed, sends an alertto a contact (e.g., via a remote device), the alert includinginformation similar to the information included in the alert providedvia the graphical user interface. In a further example, the graphicaluser interface 2000 may include a button that, when pressed, shows oneor more other actions that may be taken (e.g., additional correctiveactions).

Detecting and Correcting Vibration

Aspects of the disclosure are directed to a system that predicts anddetects vibrations and predicts, detects, and corrects conditionsresulting from vibrations.

Vibration can cause significant damage to heat exchangers and itscomponents. Vibration may be flow-induced vibration or excessivemechanical vibration, such as from nearby equipment, such as aircompressors or refrigeration machines, or from loose support structures,for example. The vibration may be caused by maldistribution, crossleakage, or fouling. Each cause of vibration may have a differentsolution. Vibration is manifested in several ways and can causeproblems/failures each of which can have different thresholds as to whatmay be a problem. The specific type of vibration phenomena may dictatedifferent types of actions to be taken. For example, shellside flowinduced vibration of heat exchanger tubes may be caused by differentmechanisms, such as fluidelastic instability or vortex shedding.Fluidelastic instability is related to a critical velocity that shouldnot be exceeded, or damage will occur, so the action would be todecrease the flow rate to avoid vibration damage. Vortex shedding isrelated to matching the natural frequency of the tube, so the actioncould be to increase the flow rate to avoid vibration damage.

There is a natural frequency of tubes or resonance that can cause damagevery quickly. Such vibrations should be detected and avoided byincreasing or decreasing the frequency of the forcing vibrations. On theother hand, acoustic vibrations might occur, which may cause noise, butare not necessarily harmful.

Mechanical vibration can cause tube failures in the form of a fatiguestress crack or erosion of tubing at the point of contact with baffles.Heat exchangers should be isolated from mechanical vibrations. Supportstructures should be reinforced or bolts tightened to avoid or lessonsuch vibrations.

The effect of shellside flow induced tube vibrations is harder to detectand correct. Shell side flow induced vibration can be caused by velocityover the tubes. If the flow through the exchanger is not uniform, thenhigh local flow velocities can cause vibration. This vibration can causetube damage in exchangers leading to frequent leakage of exchangers.Flow induced tube vibration is a large source of failure in shell andtube heat exchangers. Damage from shellside flow induced vibration caninvolve collision of tubes, wear of tubes at supports or baffles, andfatigue due to bending of tubes at fixed connections such as at thetubesheet.

Flow induced vibration can lead to mal-distribution and cross-leakage.Flow induced vibration can accelerate dislodging of corrosion particlesleading to erosion or blocked flow. Flow induced vibration mayultimately damage tubes, plates, and baffles. In some instances, flowinduced vibration may be mitigated by changing flow parameters, forexample, flow rate, pressure, temperature, vapor fraction.

Vibration may be detected with vibration sensors attached to theequipment. Vibration sensors can be placed on the shell, on the tubes,at the inlets, the outlets, the baffle locations, the midpoints betweenthe baffles, and the midpoints between the inlets and outlets. Suchsensors may measure the amplitude and frequency of sound through tubesor plates. Flow vibration may further be detected using flow sensors todetect abnormalities in flow. Flow vibration may also be detected usingpressure sensors to detect pressure drop.

Sensor information may be gathered by one or more sensors andtransmitted to data collection platform. Data collection platform maytransmit the collected sensor data to data analysis platform, which maybe at a plant or remote from a plant (e.g., in the cloud).

Data analysis platform may analyze the received sensor data. Dataanalysis platform may compare the sensor data to one or more rules todetermine if vibration is occurring. For example, vibration or damagedue to vibration may be indicated if in one or more conditions: (1) alarge change is determined over a short time frame (e.g., 10% over 3hours), (2) a smaller change is determine over a long time frame (e.g.,3% over 10 days that increase 0.3% each day), (3) the changes in thesystem match the fingerprint of prior changes that were detected and thechanges resulted in damage to the system, (4) the changes pass a presetthreshold. If abnormal or high vibrations are detected, an alarm may besignaled.

Data analysis platform may compare current sensor data to past sensordata from the heat exchanger, from other heat exchangers at the sameplant, from other heat exchangers at other plants, from a manufacturer,or the like. Data analysis platform may determine if one or more datacharacteristics of the sensor data match data that may indicatevibration or damage due to vibration. Data that may indicate vibrationor damage due to vibration may, alone or in a combination, be considereda fingerprint. When current sensor data matches a fingerprint of aparticular condition, data analysis platform may determine that thecondition is happening or potentially developing in the current systemas well. Data may be collected over many years from many differentlocations, and data analysis platform can match the current data tofingerprints of past data or situations. Thresholds used for particularrules may change or be adjusted over time based on past fingerprintscalculation tools.

From the collected data, as well as data collected from other heatexchangers, data analysis platform may run process simulations todetermine if vibration or damage due to vibration is occurring or islikely to occur. One or more possible variables may be taken intoaccount in these calculations, including temperature, pressure, flow,composition, properties of components, physical properties of fluidsbased on composition. Vibration sensor measurements may be compared withamplitude and frequency for equipment operating at normal conditionswith little or no vibration. The natural frequency of tube orfingerprint of the tube may be looked up or determined and sensor datacompared therewith. Optimal operating conditions and limits of equipment(e.g., from vendor) may be taken into account. Data analysis platformmay run process simulations to determine process conditions that may becausing the vibration.

Data analysis platform may further run process simulations to suggestchanges to flow compositions and operating parameters to avoid or limitfurther damage by vibration. In some aspects, data analysis platform maycommunicate with one or more vendors regarding the results of thesimulation, and receive recommendations from the vendor on how to changeor optimize operation or geometry of the equipment. The results of theprocess simulation may further be used to determine how quickly aproblem occurs, to identify one or more fingerprints for the problem,and/or identify one or more signatures for how the problem occurs. Dataanalysis platform may use this information to create or expand asearchable database.

In some embodiments, data from the sensors may be correlated withweather data at the plant. For example, if a rainstorm is currentlyhappening at the plant, the surface temperature, operating temperature,another temperature, and/or a pressure of the heat exchanger might drop.In another example, if a drought and heat wave are currently happeningat the plant, the surface temperature, operating temperature, anothertemperature, and/or a pressure of the heat exchanger might increase. Thedata analysis platform may determine, based on the correlation of theweather conditions to the changes in pressure data, that correspondingchanges in vibration are due to weather conditions, and not, e.g., dueto another problem.

In some embodiments, data from different types of sensors may becross-checked to confirm conclusions drawn from that data, to determinedata reliability, and the like. For example, temperature readings fromskin thermocouples may be compared to temperature readings from athermal imaging camera, thermal topography may be compared tophotographs, or the like.

In some aspects, data analysis platform may use additional data from theheat exchanger or from other equipment connected to the heat exchanger(e.g., in the same plant, in a plant upstream of the plant, etc.) todetermine additional information about the heat exchanger vibration ordamage due to vibration. For example, if vibration or damage due tovibration occurs at a consistent rate or increases at a first rate whena first operating condition exists, and the vibration or damage due tovibration occurs at the consistent rate or increases at a second ratewhen a second operating condition exists, the data analysis platform maydetermine such a correlation by comparing the heat exchanger sensor datato other data. One or more examples of an operating condition mayinclude, e.g., the plant is operated at a particular efficiency, aparticular amount of feed is used, a particular operating temperature ofa piece of equipment upstream of the heat exchanger is maintained, aparticular amount of catalyst is used, a particular temperature ofcatalyst is used, weather conditions, and the like. In some aspects, aparticular operating condition or combination of operating conditionsmay be determined to be more likely to cause development of vibration ordamage due to vibration or worsening, stability, or stabilization ofvibration or damage due to vibration.

In some aspects, data analysis platform may determine if vibration ordamage due to vibration is approaching a known failure condition. Forexample, if vibration is acceptable within a particular range, dataanalysis platform may determine whether the vibration is within theacceptable range. In another example, however, if the vibration iswithin a range or threshold of exceeding the acceptable range, dataanalysis platform may determine that the vibration may soon becomesevere enough to cause damage or equipment failure. Data analysisplatform may use historical data from the heat exchanger, data fromother heat exchangers at the plant, data from other plants, data from amanufacturer, specification data, or other data to determine howvibration might develop, stabilize, cause damage, cause failure, or thelike.

In some embodiments, data analysis platform may determine one or morefailure modes in which to classify vibration or damage due to vibration.For example, vibration or damage due to vibration may occur in more thanone way or due to more than one cause, and therefore might be detectablebased on one or more data indicators from one or more different sensortypes. Furthermore, different failure modes may be associated withdifferent corrective measures. For example, a first failure mode mightbe a result of a first problem, might be detectable by a first type ofsensor data, and might be correctable by a first action, while a secondfailure mode might be a result of a second problem, might be detectableby a second type of sensor data, and might be correctable by a secondaction.

Based on the sensor data, process simulations, fingerprint analysis,and/or other data processing, data analysis platform may determine oneor more recommended changes to operation of the heat exchanger, such asdecreasing temperature, pressure, or feed flow, or increasing recycleflow to alleviate the vibration. For example, collected data could beused to measure or calculate loss of efficiency due to vibration or costof damage due to vibration.

In some aspects, if vibration or damage due to vibration or one or moreconditions that may cause vibration or damage due to vibration aredetected, an alarm (e.g., a visual and/or audible alarm) may betriggered. The alarm could be an alarm at a plant, an alarm that is sentto one or more devices, an alarm on the heat exchanger, an alarm thatshows on a web page or dashboard, or the like.

In some aspects, if vibration or damage due to vibration is detected,control platform may take one or more actions, which may be triggered,requested, or recommended by data analysis platform. Alternatively oradditionally, data analysis platform may trigger an alert to one or moreremote devices (e.g., remote device 1, remote device 2). The alert mayinclude information about the vibration or damage due to vibration(e.g., where vibration is occurring, chemicals in vibrating equipment,history of vibration, and likelihood of damage). The alert may provideinformation about one or more determined correlations between vibrationor damage due to vibration and a particular operating condition orcombination of operating conditions. The alert may include one or morerecommendations for and/or commands causing adjustments to operatingconditions, adjustments to flows, valves, nozzles, drains, or the like.

If the extent of vibration exceeds a preset value or matches a priorvibration signature or is approaching the resonance (mechanical oracoustic) frequency of the system, corrective action may be taken. Forexample, data analysis platform may send a recommendation or a commandto control platform alter the amount of flow through or over the tubesuntil the vibration decreases.

In some aspects, a remote device may send a command for a particularaction (e.g., a corrective action) to be taken, which may or may not bebased on the alert. In some aspects, data analysis platform may send acommand for a particular action to be taken, whether or not an alert wassent to or a command was sent by the remote device. The command maycause one or more actions to be taken, which may mitigate vibration,prevent equipment (e.g., heat exchanger) damage, avoid failure, or thelike. For example, if vibration rapidly develops, and, based onanalyzing the growth rate of the vibration in view of current operatingconditions, data analysis platform determines that the vibration soonwill cross over a particular threshold (e.g., cause damage over a costthreshold, cause problems over a safety threshold or over a riskthreshold, or the like), remote device may send a command (e.g., a plantshutdown, a process shutdown, a heat exchanger shutdown, a backup heatexchanger activation, or the like) in order to avoid equipment failure,catastrophic failure, heat exchanger damage, plant damage, or some otherdamage.

Damage by vibration might not be correctable online; however, theprocess may be monitored or the feed input may be reduced into the heatexchanger in order to preserve the equipment until the next maintenanceshut down. If multiple shells are used, it may be possible to take oneshell offline for maintenance while operating the remaining shells. In aparallel shell arrangement, flow through one of the shells can be turnedoff (e.g., by control platform). In a series shell arrangement, bypasspipes may need to be built into the system, and may be activated bycontrol platform.

Aspects of the disclosure have been described in terms of illustrativeembodiments thereof. Numerous other embodiments, modifications, andvariations within the scope and spirit of the appended claims will occurto persons of ordinary skill in the art from a review of thisdisclosure. For example, one or more of the steps illustrated in theillustrative figures may be performed in other than the recited order,and one or more depicted steps may be optional in accordance withaspects of the disclosure.

What is claimed is:
 1. A system comprising: a heat exchanger; one ormore sensors associated with the heat exchanger; a data analysisplatform, comprising: one or more processors; and memory storingexecutable instructions that, when executed, cause the data analysisplatform to: receive sensor data comprising operation informationassociated with the heat exchanger; analyze the sensor data to determinewhether vibration is occurring within the heat exchanger; afterdetermining that the vibration is occurring within the heat exchanger,determine a recommended adjustment to an operating condition of the heatexchanger to reduce the vibration occurring within the heat exchanger;and send a command configured to cause the recommended adjustment to theoperating condition of the heat exchanger to reduce the vibrationoccurring within the heat exchanger.
 2. The system of claim 1, whereinthe executable instructions, when executed, cause the data analysisplatform to: responsive to determining the vibration is occurring withinthe heat exchanger, send a command to reduce a flow rate associated withthe heat exchanger.
 3. The system of claim 1, wherein the executableinstructions, when executed, cause the data analysis platform to:responsive to determining the vibration is occurring within the heatexchanger, send a command to adjust a flow parameter of a flowassociated with the heat exchanger.
 4. The system of claim 3, whereinthe executable instructions, when executed, cause the data analysisplatform to: responsive to determining the vibration is occurring withinthe heat exchanger, send a command to adjust a pressure of the flowassociated with the heat exchanger.
 5. The system of claim 3, whereinthe executable instructions, when executed, cause the data analysisplatform to: responsive to determining the vibration is occurring withinthe heat exchanger, send a command to adjust a temperature of the flowassociated with the heat exchanger.
 6. The system of claim 3, whereinthe executable instructions, when executed, cause the data analysisplatform to: responsive to determining the vibration is occurring withinthe heat exchanger, send a command to adjust a vapor fraction of theflow associated with the heat exchanger.
 7. The system of claim 1,comprising: a vibration sensor, wherein the executable instructions,when executed, cause the data analysis platform to: receive vibrationdata collected by the vibration sensor; and analyze the vibration datacollected by the vibration sensor to determine whether the vibration isoccurring within the heat exchanger.
 8. The system of claim 1,comprising: a flow sensor, wherein the executable instructions, whenexecuted, cause the data analysis platform to: receive flow datacollected by the flow sensor; and analyze the flow data collected by theflow sensor to determine whether the vibration is occurring within theheat exchanger.
 9. The system of claim 1, comprising: a pressure sensor,wherein the executable instructions, when executed, cause the dataanalysis platform to: receive pressure data collected by the pressuresensor; and analyze the pressure data collected by the pressure sensorto determine, based on a pressure drop across the heat exchanger,whether the vibration is occurring within the heat exchanger.
 10. Thesystem of claim 1, wherein the executable instructions, when executed,cause the data analysis platform to: compare the sensor data comprisingthe operation information associated with the heat exchanger to pastsensor data associated with the heat exchanger to determine whetherthere is a deviation greater than a threshold deviation between thesensor data and the past sensor data.
 11. The system of claim 1, whereinthe executable instructions, when executed, cause the data analysisplatform to: compare the sensor data comprising the operationinformation associated with the heat exchanger to different sensor dataassociated with a different heat exchanger of a same type as the heatexchanger to determine whether there is a deviation greater than athreshold deviation between the sensor data and the different sensordata.
 12. The system of claim 1, wherein the executable instructions,when executed, cause the data analysis platform to: correlate the sensordata comprising the operation information associated with the heatexchanger with weather data corresponding to weather at a geographiclocation of the heat exchanger and a time that the sensor data wascollected; and determine, based on correlating the sensor data with theweather data, whether the weather at the geographic location of the heatexchanger caused the vibration occurring within the heat exchanger. 13.The system of claim 1, wherein the executable instructions, whenexecuted, cause the data analysis platform to: responsive to determiningthe vibration is occurring within the heat exchanger, trigger an alarm.14. The system of claim 1, wherein the executable instructions, whenexecuted, cause the data analysis platform to: cause display of therecommended adjustment to the operating condition of the heat exchangeron a graphical user interface of a computing device.
 15. One or morenon-transitory computer-readable media storing executable instructionsthat, when executed, cause a system to: receive sensor data comprisingoperation information associated with a heat exchanger; analyze thesensor data to determine whether vibration is occurring within the heatexchanger; and after determining the vibration is occurring within theheat exchanger, determine a recommended adjustment to an operatingcondition of the heat exchanger to reduce the vibration occurring withinthe heat exchanger.
 16. The one or more non-transitory computer-readablemedia of claim 15, storing executable instructions that, when executed,cause the system to: receive first sensor data comprising first flowdata measured by a first flow sensor associated with a first passagealong a flow length associated with the heat exchanger, the first flowdata associated with the first passage along the flow length associatedwith the heat exchanger; receive second sensor data comprising secondflow data measured by a second flow sensor associated with a secondpassage along the flow length associated with the heat exchanger, thesecond flow data associated with the second passage along the flowlength associated with the heat exchanger; determine whether adifference between the first flow data associated with the first passageand the second flow data associated with the second passage is greaterthan a threshold; and based on determining that the difference betweenthe first flow data associated with the first passage and the secondflow data associated with the second passage is greater than thethreshold, determine that the vibration is occurring within the heatexchanger.
 17. The one or more non-transitory computer-readable media ofclaim 15, storing executable instructions that, when executed, cause thesystem to: receive vibration data collected by a vibration sensorassociated with the heat exchanger; and analyze the vibration datacollected by the vibration sensor to determine whether the vibration isoccurring within the heat exchanger.
 18. A method comprising: receiving,by a data analysis computing device, sensor data comprising operationinformation associated with a heat exchanger; analyzing, by the dataanalysis computing device, the sensor data to determine whethervibration is occurring within the heat exchanger; and after determiningthe vibration is occurring within the heat exchanger, determining, bythe data analysis computing device, a recommended adjustment to anoperating condition of the heat exchanger to reduce the vibrationoccurring within the heat exchanger.
 19. The method of claim 18,comprising: receiving, by the data analysis computing device, vibrationdata collected by a vibration sensor associated with the heat exchanger;and analyzing, by the data analysis computing device, the vibration datacollected by the vibration sensor to determine whether the vibration isoccurring within the heat exchanger.
 20. The method of claim 18,comprising: responsive to determining the vibration is occurring withinthe heat exchanger, sending, by the data analysis computing device, acommand to adjust a flow parameter of a flow associated with the heatexchanger.